Systems and methods for generating and consuming power from natural gas

ABSTRACT

Systems and methods are provided to mitigate flaring of natural gas. A natural gas processing system may process raw natural gas into a fuel gas stream that may be used to power any number of on-site power generation modules. In turn, the power generation modules may convert the fuel gas stream into an electrical output, which may be employed to power any number of distributed computing units housed within one or more mobile data centers. In certain embodiments, the distributed computing units may be adapted to mine cryptocurrency or perform other distributed computing tasks to generate revenue.

CROSS-REFERENCE TO RELATED APPLICATIONS

The present application is a continuation application of U.S. utilitypatent application Ser. No. 17/087,928, titled “Systems and Methods forGenerating and Consuming Power from Natural Gas,” filed Nov. 3, 2020,which is a continuation application of U.S. utility patent applicationSer. No. 16/694,883, titled “Systems and Methods for Generating andConsuming Power from Natural Gas,” filed Nov. 25, 2019, which is acontinuation application of U.S. utility patent application Ser. No.16/529,152, titled “Systems and Methods for Generating and ConsumingPower from Natural Gas,” filed Aug. 1, 2019, which claims benefit ofU.S. provisional patent application No. 62/713,368, titled “Systems andMethods for Generating and Consuming Power from Natural Gas,” filed Aug.1, 2018. Each of the above applications is incorporated by referenceherein in its entirety.

BACKGROUND

This specification relates to enabling the utilization of raw naturalgas, such as flare gas, stranded gas, and associated gas for powergeneration. More specifically, the specification relates to on-sitegeneration of electricity from natural gas to power modular processingunits adapted to perform distributed computing tasks.

Extracting oil from unconventional resources, such as shale gasformations, through the combination of horizontal drilling and hydraulicfracturing has increased at a rapid pace in recent years. The Bakken,Powder River Basin, Denver Julesburg (“D-J”) Basin, North Park Basin,and Permian Basin are just some of the important “plays” in the UnitedStates. A “play” is the geographic area underlain by a gas- oroil-containing geologic formation.

Development of these gas plays and other unconventional resourcespresents significant potential for economic development and energyindependence, but also presents the potential for environmental impactson land, water and air. For example, although oil production representsthe most important source of revenue for a given well, most wells alsoproduce natural gas as a low-value byproduct. Unfortunately, theliquids-rich natural gas byproduct often cannot be economicallytransported by trucks or trains from remote well locations. Althoughsuch natural gases could be transported via pipelines, many oil andnatural gas wells are located beyond the reach of such infrastructure.Absent gas pipeline infrastructure, oil well operators must either“vent” or “flare” produced gasses for safety reasons. Venting is thecontrolled release of natural gases into the atmosphere in the course ofoil and gas production operations, however natural gas accumulationsaround the wellbore create significant safety hazards. Flaring is thecontrolled burning of natural gas produced in association with oil inthe course of routine oil and gas production operations, and is designedto minimize the safety and environmental risks associated with ventinguncombusted natural gas.

As of April 2016, the NOAA estimates that there are over 6,200individual flares in the United States, which burn about 35 billion ft³of natural gas annually—enough to supply about 6 million homes. Suchlarge-scale flaring of natural gas has raised serious environmental andhealth concerns and various state and federal regulators have begun totake action by implementing strict regulations and enforcement policies.For example, Colorado generally limits flaring to 60 days and many newwell permits require producers to have a natural gas offtake solutionprior to production; North Dakota has recently implemented a requirementthat 90% of associated gas be captured by 2020; and Texas only allowsnew wells to flare for 10 days before an additional 45-day permit mustbe obtained. The EPA has also implemented flaring regulations wheresites that exceed 100 tons per year of VOC, CO or NOX trigger Title V“Major Source Emitter” rules. Violations of state or federal rules canresult in oil wells being “shut in,” rejected permits and/or significantcash fines.

Stranded natural gas, particularly in the case where liquids-weightedwells are shut in due to gas takeaway constraints, represents a verylow-cost power generation opportunity. Stranded gas exists across mostprominent shale fields today including in the D-J Basin, Permian Basin,Bakken, SCOOP/STACK, etc. Many oil and gas operators inpipeline-constrained environments readily offer their natural gas forlow cost—even at a loss to the operator in some cases—so that they canproduce oil, which often represents the vast majority of a well'slifetime economics.

One potential solution to the natural gas problem lies in distributedcomputing. Cryptocurrency is a booming asset class with the combinedmarket capitalization of digital currencies surpassing $380 billion inJuly 2018. Cryptocurrencies operate on a distributed system of computers“mining” the currencies—essentially processing the underlying algorithmsto continuously verify transactions and account balances. The cryptomining process is a significant industry in its own right, projected toreach a value of $39 billion by 2025 with a projected CAGR of 29.7%.

This high-growth industry requires innovative and inexpensiveelectricity sources as it requires enormous amounts ofpower—approximately 29 TWh of electricity per year on a global basis.For perspective, cryptocurrency mining consumes more power annually than159 countries, including Hungary, Ireland, Nigeria or Slovakia. Indeed,electricity is typically the single largest lifetime cost to acryptocurrency mining operation, with power costs offsettingapproximately 30% of total mining revenues in the US.

Accordingly, there remains a need for systems and methods for generatingelectricity from natural gas produced from oil wells. It would bebeneficial if such electricity could be produced and consumed on-site,for example, by using it to operate power-intensive, modular processingunits. It would be further beneficial if such processing units could beemployed to mine cryptocurrency or perform other distributed computingtasks to generate additional revenue.

SUMMARY

In accordance with the foregoing objectives and others, exemplarysystems and methods are disclosed herein to convert raw natural gas intoa fuel gas stream that may be used to power any number of on-site powergeneration modules. In turn, the power generation modules may convertthe fuel gas stream into electricity, which may be employed to power anynumber of modular distributed computing units. In certain embodiments,the distributed computing units may be adapted to mine cryptocurrency orperform other distributed computing tasks to generate revenue.

In one embodiment, a flare mitigation system is provided. Such systemmay include an electrical power generation system, which may include apower generation module adapted to: receive a fuel gas stream, such as afuel gas associated with a heat value of at least about 1,000 Btu/scf;and consume the fuel gas stream to generate a high-voltage electricaloutput associated with a first voltage. The electrical power generationsystem may also include an electrical transformation module inelectrical communication with the power generation module, theelectrical transformation module adapted to: receive the high-voltageelectrical output generated by the power generation module; andtransform the high-voltage electrical output into a low-voltageelectrical output associated with a second voltage that is lower thanthe first voltage.

The flare mitigation system may also include a distributed computingsystem powered by the electrical power generation system. Thedistributed computing system may include a communications system withone or more data satellite antennas in order to provide a network; and afirst mobile data center. The mobile data center may include anenclosure defining an interior space; a plurality of distributedcomputing units located within the interior space of the enclosure, eachof the plurality of distributed computing units in communication withthe network; and a power system located at least partially within theinterior space of the enclosure, the power system in electricalcommunication with the electrical transformation module and theplurality of distributed computing units such that the power systemreceives the low-voltage electrical output and powers each of theplurality of distributed computing units.

In some cases, the power generation module may be an engine-typegenerator that generates a high-voltage electrical output of from about70 kW to about 2 MW (e.g., from about 70 kW to about 300 kW, from about300 kW to about 400 kW, 400 kW to about 1 MW, or from about 1 MW toabout 2 MW). The first voltage of the high-voltage electrical output maybe from about 480 V to about 4.16 kV. And the second voltage of thelow-voltage electrical output may be from about 208 V to about 240 V.

In other cases, the power generation module may be a turbine-typegenerator that generates a high-voltage electrical output of from about2 MW to about 30 MW. In such cases, the first voltage of thehigh-voltage electrical output may be from about 4.16 kV to about 12 kV.And the second voltage of the low-voltage electrical output may be fromabout 208 V to about 240 V.

In another embodiment, a flare mitigation system is provided. The systemmay include an electrical power generation system having a first powergeneration module and a second power generation module. The first powergeneration module may be adapted to receive a first fuel gas stream,such as a fuel gas associated with a heat value of at least about 1,000Btu/scf, and to consume the fuel gas stream to generate a firsthigh-voltage electrical output associated with a first voltage. Thesecond power generation module may be adapted to receive a second fuelgas stream including the fuel gas, and to consume the second fuel gasstream to generate a second high-voltage electrical output associatedwith the first voltage.

The electrical power generation system may also include a parallel panelin electrical communication with the first power generation module andthe second power generation module. The parallel panel may be adapted toreceive the first and second high-voltage electrical outputs; andcombine and/or synchronize the first and second high-voltage electricaloutputs into a combined high-voltage electrical output.

The electrical power generation system may also include an electricaltransformation module in electrical communication with the parallelpanel. The electrical transformation module may be adapted to receivethe combined high-voltage electrical output; and transform the combinedhigh-voltage electrical output into a low-voltage electrical outputassociated with a second voltage that is lower than the first voltage.

The flare mitigation system may further include a distributed computingsystem powered by the electrical power generation system. Thedistributed computing system may include a communications system havingone or more data satellite antennas in order to provide a network.Moreover, the distributed computing system may include a first mobiledata center having an enclosure defining an interior space; a pluralityof distributed computing units located within the interior space of theenclosure, each of the plurality of distributed computing units incommunication with the network; and a power system located at leastpartially within the interior space of the enclosure, the power systemin electrical communication with the electrical transformation moduleand the plurality of distributed computing units such that the powersystem receives the low-voltage electrical output and powers each of theplurality of distributed computing units.

The details of one or more embodiments of the subject matter of thisspecification are set forth in the accompanying drawings and thedescription below. Other features, aspects, and advantages of thesubject matter will become apparent from the description, the drawings,and the claims.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 shows an exemplary flare mitigation system 100 according to anembodiment.

FIG. 2 shows an exemplary natural gas processing system 200 according toan embodiment.

FIG. 3 shows an exemplary electrical power generation system 300comprising a power generation module 331 in electrical communicationwith an electrical transformation module 335.

FIG. 4 shows another exemplary electrical power generation system 400comprising a plurality of power generation modules (431 a, 431 b) inelectrical communication with an electrical transformation module 435via a parallel panel 460.

FIG. 5 shows an exemplary distributed computing system 500 according toan embodiment.

FIG. 6 shows an exemplary computing machine 600 and modules 650according to an embodiment.

DETAILED DESCRIPTION

System Overview

Referring to FIG. 1, an exemplary flare mitigation system 100 accordingto an embodiment is illustrated. As shown, the system 100 may comprise anatural gas processing system 120, an electrical power generation system130, a distributed computing system 140, a communication system 155 anda monitoring and control system 180.

In one embodiment, the flare mitigation system 100 may comprise anatural gas processing system 120 adapted to receive a raw natural gasstream 101 from one or more wellheads 110 in an oil and/or gasreservoir. The natural gas processing system 120 is generally adapted toconvert the received raw natural gas 101 into a fuel gas stream 102 thatmay be introduced to an electrical power generation system 130. Asdiscussed in detail below with respect to FIG. 2, the natural gasprocessing system 120 may employ a separator module and, optionally, anynumber of additional modules (e.g., a compressor module, a carbondioxide removal module, a desulfurization module and/or a refrigerationmodule) to produce a fuel gas stream 102 meeting the specificrequirements of the electrical power generation system 130 and anynumber of secondary streams.

The electrical power generation system 130 generally comprises anynumber of power generation modules adapted to consume the fuel gas 102and convert the same into electrical power. As discussed in detail belowwith respect to FIGS. 3-4, each power generation module may be inelectrical communication with an electrical transformation moduleadapted to receive the electrical output of the power generationmodule(s) and convert the same into an electrical flow 105 that may beemployed to power the electrical components of a distributed computingsystem 140.

In one embodiment, the distributed computing system 140 may comprise anynumber distributed computing units (“DCUs”) in electrical communicationwith the electrical power generation system 130, such that the DCUs arepowered via the electrical flow 105 output by the system. The DCUs maycomprise a modular computing installation, for example, a data center,cryptocurrency mine or graphics computing cell. And the DCUs aregenerally adapted to conduct any number of processing-intensive tasks.For example, the DCUs may be employed to execute graphics-intensivedistributed computing processes, artificial intelligence (“AI”)research, machine learning model training, data analysis, serverfunctions, storage, virtual reality and/or augmented realityapplications, tasks relating to the Golem Project, non-currencyblockchain applications and/or cryptocurrency mining operations.

In certain embodiments, the DCUs may be employed to execute mathematicaloperations in relation to the mining of cryptocurrencies includingcomputing the following hashing algorithms: SHA-256, ETHash, scrypt,CryptoNight, RIPEMD160, BLAKE256, X11, Dagger-Hashimoto, Equihash, LBRY,X13, NXT, Lyra2RE, Qubit, Skein, Groestl, BOINC, X11gost, Scrypt-jane,Quark, Keccak, Scrypt-OG, X14, Axiom, Momentum, SHA-512, Yescrypt,Scrypt-N, Cunningham, NIST5, Fresh, AES, 2Skein, Equilhash, KSHAKE320,Sidechain, Lyra2RE, HybridScryptHash256, Momentum, HEFTY1, Skein-SHA2,Qubit, SpreadX11, Pluck, and/or Fugue256. Additionally or alternatively,the DCUs may be adapted to execute mathematical operations in relationto training computationally intensive machine learning, artificialintelligence, statistical or deep learning models, such as neuralnetworks, recurrent neural networks, convolutional neural networks,generative adversarial networks, gradient boosting machines, randomforests, classification and regression trees, linear, polynomial,exponential and generalized linear regressions, logistic regression,reinforcement learning, deep reinforcement learning, hyperparameteroptimization, cross validation, support vector machines, principalcomponent analysis, singular value decomposition, convex optimization,and/or independent component analysis.

As discussed in detail below with respect to FIG. 5, the distributedcomputing system 140 may comprise one or more mobile data centers,wherein each mobile data center houses a plurality of DCUs therein. Inaddition to the DCUs, each mobile data center may further house anelectrical power system, one or more backup power systems, anenvironment control system, and/or various monitoring and controlequipment 183.

In certain embodiments, the mobile data center (and any electroniccomponents contained therein) may be in communication with acommunication system 155. For example, the mobile data center may be indirect communication with the communication system 155 via a wiredconnection. As another example, the DCUs may be in indirectcommunication with the communication system 155 via a network 150.

In one embodiment, the communication system 155 may comprise one or moredata satellite antennas in communication with one or more high-orbitand/or low-orbit satellites. The antennas may be roof-mounted to one ormore mobile data centers and/or may be pole-mounted into the groundnearby such mobile data centers. A typical configuration is for twoantennas to serve a single mobile data center in order to providereliability and redundancy; however, a single antenna may be sufficientdepending on bandwidth requirements and total DCU count. Alternatively,many (e.g., three or more) antennas may be mounted to a roof of a singlemobile data center, and communications cables may extend from the mobiledata center to other nearby mobile data centers to provide a centralizedcommunications solution.

The one or more data satellite antennas of the communication system 155may be specified for continuous outdoor use, and may be installed usingrobust mounting hardware to ensure alignment even during heavy wind orother storms common in the oilfield. Antenna modems may be housed insidea mobile data center for warmth, security and weatherproofing, and suchmodems may be connected to the power system of the mobile data center.

In one embodiment, the communication system 155 may provide an internalnetwork that includes automatic load-balancing functionality such thatbandwidth is allocated proportionately among all active antennas. Insuch embodiment, if a single antenna fails, the lost bandwidth isautomatically redistributed among all functioning antennas. This is animportant reliability feature for oilfield operations, where equipmentfailures due to storms are possible.

In another embodiment, the antennas and satellite internet systems ofthe communication system 155 may be specified based on the needs of thedistributed computing system 140, with specific attention paid tobandwidth and latency requirements. For lower bandwidth applicationssuch as certain blockchain processing, cryptocurrency mining and/orlong-term bulk data processing jobs, high-orbit satellite connectivityranging from 10 MB/s to 100 MB/s may be specified. For higher bandwidthor low latency requirements such as artificial intelligence modeltraining, iterative dataset download and boundary spamming projects,visual processing such as images or videos, natural language processing,iterative protein folding simulation jobs, videogaming, or any otherhigh capacity data streaming or rapid communication jobs, low-orbitsatellites may be specified to provide significantly increased speedsand reduced latency.

In any event, the communication system 155 may provide a network 150 towhich various components of the flare mitigation system 100 may beconnected. The network 150 may include wide area networks (“WAN”), localarea networks (“LAN”), intranets, the Internet, wireless accessnetworks, wired networks, mobile networks, telephone networks, opticalnetworks, or combinations thereof. The network 150 may be packetswitched, circuit switched, of any topology, and may use anycommunication protocol. Communication links within the network 150 mayinvolve various digital or an analog communication media such as fiberoptic cables, free-space optics, waveguides, electrical conductors,wireless links, antennas, radio-frequency communications, and so forth.

As shown, the flare mitigation system further 100 comprises a MC system180, which is generally adapted to maintain processing conditions withinacceptable operational constraints throughout the system. Suchconstraints may be determined by economic, practical, and/or safetyrequirements. The MC system 180 may handle high-level operationalcontrol goals, low-level PID loops, communication with both local andremote operators, and communication with both local and remote systems.The MC system 180 may also be in communication with ancillary systems,such as storage systems, backup systems and/or power generation systems.

In one embodiment, the MC system 180 may be in communication withvarious monitoring and control equipment (181-183), such as sensorsand/or controllers, via the network 150. Such monitoring and controlequipment (181-183) may be in further communication with variouscomponents of the natural gas processing system 120, the electricalpower generation system 130 and/or the distributed computing system 140,such that the MC system 180 may remotely monitor and control operatingparameters throughout the flare mitigation system 100. Exemplaryoperating parameters may include, but are not limited to, profile of theraw natural gas supply, gas flow rate at various locations, gas pressureat various locations, temperature at various locations, electricaloutput at one or more locations, electrical load at one or morelocations, and/or others.

As an example, the MC system 180 may determine a change in the profile,flow rate and/or pressure of the raw natural gas 101 and thenautomatically modulate electrical load of a mobile data centeraccordingly. And as another example, the MC system 180 may automaticallyreduce a processing rate of one or more DCUs in response to receiving anindication that supply gas pressure has decreased.

In one embodiment, any number of users may access the MC system 180and/or the distributed computing system 140 via a client device 160 incommunication with the network 150. Generally, a client device 160 maybe any device capable of accessing such systems (e.g., via a nativeapplication or via a web browser). Exemplary client devices 160 mayinclude general purpose desktop computers, laptop computers,smartphones, and/or tablets. In other embodiments, client devices 160may comprise virtual reality (“VR”) and/or augmented reality (“AR”)hardware and software, which allow users to provide input via physicalgestures.

The relationship of the client device 160 to such systems arises byvirtue of computer programs running on the respective computers andhaving a client-server relationship to each other. Accordingly, each ofthe client devices 160 may have a client application running thereon,where the client application may be adapted to communicate with a MCapplication running on a MC system 180 and/or a distributed computingapplication running on a distributed computing system 140, for example,over a network 150. Thus, the client application may be remote from theMC system 180 and/or the distributed computing system 140. Such aconfiguration may allow users of client applications to interact withone or both of such systems from any location. Moreover, because the MCsystem 180 is capable of transceiving information to/from the variousother systems (e.g., natural gas processing system 120, electrical powergeneration system 130, distributed computing system 140, andcommunication system 155), a user may interact with such systems via theMC system.

As discussed in detail below, one or more MC system applications and/ordistributed computing system applications may be adapted to presentvarious user interfaces to users. Such user interfaces may be based oninformation stored on the client device 160 and/or received from therespective systems. Accordingly, the application(s) may be written inany form of programming language, including compiled or interpretedlanguages, or declarative or procedural languages, and it can bedeployed in any form, including as a standalone program or as a module,component, subroutine, or other unit suitable for use in a computingenvironment. Such software may correspond to a file in a file system. Aprogram can be stored in a portion of a file that holds other programsor data. For example, a program may include one or more scripts storedin a markup language document; in a single file dedicated to the programin question; or in multiple coordinated files (e.g., files that storeone or more modules, sub programs, or portions of code).

Each of the MC system application(s) and/or distributed computing systemapplication(s) can be deployed and/or executed on one or more computingmachines that are located at one site or distributed across multiplesites and interconnected by a communication network. In one embodiment,an application may be installed on (or accessed by) one or more clientdevices 160.

In certain embodiments, the MC system 180 and/or the client device 160may be adapted to receive, determine, record and/or transmit applicationinformation relating to one or more components of the flare mitigationsystem 100. The application information may be received from and/ortransmitted to the natural gas processing system 120, the electricalpower generation system 130 and/or the distributed computing system 140via, for example, monitoring and/or control equipment (181, 182, 183,respectively) in communication with one or more components of suchsystems and in further communication with the network 150. Moreover, anyof such application information may be stored in and/or retrieved fromone or more local or remote databases (e.g., database 185).

In one embodiment, the MC system 180 may be connected to one or morethird-party systems 170 via the network 150. Third-party systems 170 maystore information in one or more databases that may be accessed by theMC system 180. The MC system 180 may be capable of retrieving and/orstoring information from third-party systems 170, with or without userinteraction. Moreover, the MC system may be capable of transmittingstored/received information to such third-party systems.

It will be appreciated that various components of the flare mitigationsystem 100 may be modular such that they may be combined to form amodular system. For example, the modular components that make up thenatural gas processing system 120, the electrical power generationsystem 130, the distributed computing system, and/or the communicationsystem 155 may be transported to an oil filed and assembled into therespective subsystems of the flare mitigation system 100.

In one embodiment, the natural gas processing system 120, electricalpower generation system 130, distributed computing system 140 and thecommunication system 155 may be designed to allow all components of suchsystems to fit inside the height and width of a portable container, suchas a shipping container or similar prefabricated enclosure that istransportable using a standard drop-deck semi-trailer. It will beappreciated that such configuration allows for enhanced mobility of theflare mitigation system 100 to various field sites.

Moreover, some or all of the aforementioned systems/components may bepre-mounted to a fixed skid, wheeled trailer or other form of mountingbrackets in order to simplify and expedite transportation. Key benefitsof this approach include reduced assembly time and expense in the field,where oilfield contract labor is often more expensive than shop labor,and where contractor availability (such as electricians) may beconstrained. Wheel-mounted solutions may also qualify for specialtreatment as “temporary equipment,” facilitating expedited or reducedregulatory processing in the oilfield environment. Pre-mountingequipment also allows for an operator to quickly re-mobilize the system100 to a new site if the original gas flow associated with the originalwell declines or a new area experiences a greatly increased demand forflare mitigation.

It will be further appreciated that, the natural gas processing system120, electrical power generation system 130, distributed computingsystem 140 and/or the communication system 155 may be designed to allowfor individual components of such subsystems to be added or removed, asnecessary, to provide a flare mitigation system 100 that aims to consumesubstantially all raw natural gas 101 produced at the wellhead 110. Thisconfiguration is important, as each well's gas flow rate, pressure andcomposition will be unique and may change over time.

For example, the electrical power generation system 130 may be modifiedto include additional power generation modules and/or electricaltransformation modules and the distributed computing system 140 may bemodified to include additional mobile data centers to mitigateincreasingly larger volumes of gas during initial flow back and peakproduction phases of a well's life. Conversely, modules may be removedto accommodate declining flow rates. As another example, individual DCUswithin a mobile data center of the distributed computing system 140 canalso be remotely “turned down” or turned off to fit gas demand with gasproduction at each individual wellhead 110.

Using the above-described system 100, inexpensive and abundant strandedgas 101 can be used to power multi-megawatt-scale power generationequipment to produce power 105 for on-site or adjacent cryptocurrencymining operations. For example, the system may consume raw natural gashaving a heat value of at least 1,000 Btu/scf at a rate of 1.3 MMscfd topower approximately 3,300 DCUs having a 14 TH/s mining hash rate (e.g.,ANTMINER S9 mining rigs), which is equivalent to a moderate scalecommercial mining operation. The cost to power this same miningoperation would be about $2.6 million annually under a commercial powerpurchase agreement ($0.06/kwh).

Natural Gas Processing System

Referring to FIG. 2, an exemplary natural gas processing system 200according to an embodiment is illustrated. As shown, the system 200 maycomprise a separator module 210 and various optional components, such asa compressor module 215, a CO₂ removal module 222, a desulfurizationmodule 224, a dehydrator module 226 and/or a refrigerator module 230.

Generally, the natural gas processing system 200 is adapted to convert araw natural gas stream 201 received from one or more oil and/or gaswellheads 209 into a fuel gas stream 202 and, optionally, varioussecondary streams. As used herein, the term “raw natural gas” or “rawgas” means unprocessed natural gas released during oil and/or gasproduction. Raw natural gas 201 may also be referred to as “associatedgas,” “flare gas,” “produced gas,” and/or “stranded gas.”

Raw natural gas 201 at a wellhead 209 is commonly a mixture ofhydrocarbons, including methane (CH₄), ethane (C₂H₆), propane (C₃H₈),butane (C₄H₁₀), pentane (C₅H₁₂), hexane (C₆H₁₄) and higher hydrocarbons.The raw natural gas 201 also contains other compounds such as watervapor (H₂O), hydrogen sulfide (H₂S), carbon dioxide (CO₂), oxygen (O₂),and nitrogen (N₂). Table 1, below, shows properties of exemplary raw gasfrom wellheads in the Bakken Formation.

TABLE 1 Exemplary Raw Natural Gas Properties Component Value Methane48-85 mol % Ethane 12-20 mol % Propane 5-15 mol % Butane+ (C4+) 4-17 mol% CO₂ + N₂ 1.5-3.5 mol % H₂S 0-2.0 mol % Heat Value 1,200-1,715 Btu/scfWobbe Index 43-57 H₂O 10-50 lbs/MMscf

As used herein, the term “fuel gas” 202 refers to a natural gas streamthat has been processed by a natural gas processing system 200 such thatit may be used by an electrical power generation system (e.g., FIG. 1 at130) to generate electrical power for a distributed computing system(FIG. 1 at 140). It will be appreciated that the properties of the fuelgas 202 produced by the natural gas processing system 200 may varydepending on the raw natural gas and requirements of the employedelectrical power generation system.

Nevertheless, the fuel gas 202 will typically comprise a heat value ofat least about 1,000 Btu/scf and a methane content of at least about80%. In some embodiments, the fuel gas 202 may be processed to containless than about 1% pentane and higher hydrocarbons (C5+) components.Moreover, such fuel gas 202 may be optionally be processed to containless than about 5% propane and higher hydrocarbons (C3+) components.

In some embodiments, the produced fuel gas 202 may be substantially freeof particulate solids and liquid water to prevent erosion, corrosion orother damage to equipment. Moreover, the fuel gas may be dehydrated ofwater vapor sufficiently to prevent the formation of hydrates duringdownstream processing. And, in certain embodiments, the produced fuelgas 202 may contain no more than trace amounts of components such asH₂S, CO₂, and N₂.

As shown, the raw natural gas 201 received from the wellhead 209 mayfirst be introduced to a separator module 210 such that liquids (e.g.,oil 291 and/or water 292) may be separated and removed therefrom.Generally, the separator module 210 may comprise at least onemulti-phase separator, such as a 2-phase separator (separating liquidsand gas), or a 3-phase separator (separating oil, water, and gas),

In one particular embodiment, the separator module 210 comprises a3-phase separator. An exemplary 3-phase separator may comprise a vesselhaving an inlet to receive the raw natural gas 201, an outlet throughwhich free gas exits the vessel, an outlet through which water exits thevessel, and an outlet through which oil exits the vessel. Upon enteringthe vessel, the raw gas 201 may encounter an inlet deflector, whichcauses initial separation of gas from a liquid mixture of oil and water.The free gas may then rise within the vessel, while the heavier liquidmixture descends therewithin. And, optionally, a divertor may beemployed within the vessel to redirect flow of the liquid mixture and toallow it to settle more readily within the vessel.

Once separated from the liquid, the free gas may flow through a mistextractor that removes any entrained liquids remaining in the gas. Theresulting gas stream then flows out of the top of the separator vessel,through the gas outlet.

As the liquid mixture settles within the separator vessel, the oilseparates from the water and rises out of solution. In one embodiment, aweir plate may be employed to allow the oil to pour into an oil chamberor bucket, while preventing the water from entering the chamber.Additionally, the separator may include a metal protector plate to blockany splashing liquid from entering the gas outlet.

Generally, the recovered oil 291 can be directed to an oil storage tankor may be transported for sale via truck, rail or pipe. And the water292 may be sent to a water storage tank, treated on-site, disposed of,and/or transported to a wastewater treatment facility or otherreclamation zone.

In one embodiment, the separator module 210 may comprise, or otherwisebe placed in communication with, various monitoring and/or controlequipment. Such equipment may be adapted to measure, determine and/orcontrol various operating parameters at any number of locationsthroughout the separator module 210. As discussed above, such equipmentmay be in communication with a remote MC system (e.g., via a network) toallow for both (1) remote monitoring and control of the separator module210 by any number of operators and (2) automatic control thereof.

As an example, the separator module 210 may comprise any number ofpressure monitors, flow meters, regulators and/or control valves tomonitor/control gas and/or liquid processing parameters (e.g.,inlet/outlet pressure, inlet/outlet flow, level, etc.). Such equipmentmay be located within one or more vessels, on one or more inlets and/oron one or more outlets of the separator module 210.

It will be appreciated that the separator module 210 may furthercomprise any number of safety valves adapted to direct flow to a safeand contained area upon overpressurization of the vessel. In oneembodiment, the separator module may comply with ASME VIII, Division 1and NACE MR-0175 for H2S environments. Additionally or alternatively,the separator module may comprise a skid designed to SEPCO OPS055 and/orAPI RP2A standards.

In certain embodiments, the separator module 210 may further comprise aheater-treater component located upstream of the multi-phase separatoror integral therewith. Generally, the heater-treater may comprises apressurized vessel, or a series of pressurized vessels, in which abottom-mounted, heat source is operated. During operation, theheater-treater heats the raw natural gas 201 received from the wellhead209 by means of direct contact with the heat source and the ensuingtemperature increase reduces molecular attraction between oil and watermolecules contained therein. Accordingly, when the heated raw naturalgas is passed to the multi-phase separator, water droplets may settleout of the liquid more rapidly.

In one embodiment, the gas stream produced by the separator module 210may be of a sufficient quality to be directly utilized as fuel gas 202for a power generation module of the electrical power generation system.In such cases, the resulting gas stream 202 may not be introduced to anyof the optional processing modules shown in FIG. 2; rather, it may betransferred directly to an electrical power generation module. It willbe appreciated that, although the illustrated optional processingmodules are not employed in this embodiment, the fuel gas 202 may beaggregated (e.g., in a field gathering pipeline) before being introducedto the electrical power generation module. Additionally oralternatively, conventional valves and/or compressors may be employedupstream of the electrical power generation module to regulate thepressure of the fuel gas 202.

In other embodiments, the gas stream produced by the separator module210 may require additional processing upstream of the power generationmodule. In such cases, the natural gas processing system 200 maycomprise one or more of: a compressor module 215, a CO₂ removal module222, a desulfurization module 224, a dehydrator module 226 and/or arefrigeration module 230.

Generally, a compressor module 215 may be employed to increase thepressure of the gas stream from an initial pressure of from about 15 psito about 50 psi, to a final pressure of from about 150 psi to about 350psi. Such pressure increase may be desired or required when arefrigeration module 230 is employed (discussed below) and/or in caseswhere the fuel gas 202 is to be introduced to a power generation modulecomprising a turbine.

As a result of the pressure increase, the compressor module 215 may alsoremove heavy natural gas liquids (“NGLs”) stream 293 comprising pentaneand higher hydrocarbons (C5+) from the natural gas. To that end, thecompressor module 215 may comprise any number of individual compressorunits operating to raise and lower the pressure of the received gasstream, during any number of compression stages, such that the NGLs 293contained therein may be liquified and removed. The resulting NGLsstream 293 may exit the compressor module 215 and may be stored in astorage tank and/or transported for sale via truck, rail or pipe.

Accordingly, the compressor module 215 may produce a resulting gasstream comprising methane, ethane, propane, and butane, wherein the gasstream is substantially free of pentane and higher hydrocarbons (C5+).That is, the resulting compressed gas stream will typically compriseless than about 1% C5+ hydrocarbons, such that the stream comprises aheat content of from about 1,200 Btu/scf to about 1,500 Btu/scf.

In one embodiment, the compressor module 215 may comprise any number ofindividual compressor units. The compressor units may be driven byeither conventional piston engines or natural gas turbines, and suchunits are typically fueled by a portion of the natural gas (althoughsome or all of the units may be electrically powered if required). Thecompressor units typically operate in parallel, although some or all ofthe compressor units may be operated in stages (serially) as desired orrequired.

As the gas is compressed, heat is generated and must be dissipated tocool the gas stream before leaving the compressor module. Accordingly,the compressor module 215 may comprise an aerial cooler system todissipate excess heat (e.g., an “after cooler”). Additionally, the heatgenerated by operation of the individual compressor units may bedissipated via a sealed coolant system.

The compressor module 215 may comprise, or otherwise be placed incommunication with, various monitoring and/or control equipment adaptedto monitor and/or control operating parameters (e.g., gas flow and/orpressure) across all compressor units. Such equipment may be incommunication with the remote MC system (e.g., via a network) to allowfor remote monitoring and control of the compressor module 215 by anynumber of operators and/or for automatic control thereof.

In certain embodiments, the natural gas processing system 200 mayinclude a CO₂ removal module 222 to remove CO₂ 294 from the gas stream.Generally, the CO₂ removal module 222 will be employed, as required, tomeet pipeline specifications. For example, the CO₂ removal module 222may be employed to reduce CO₂ content in the gas stream to less thanabout 1% CO₂.

In one embodiment, the CO₂ removal module 222 may comprise one or moremembranes, such as a spiral-wound cellulose acetate membrane. Generally,the membrane operates on the principle of selective permeation, wherecomponents with higher permeation rates (e.g., CO₂) permeate through amembrane faster than those with lower permeation rates (e.g., methane,ethane and heavier hydrocarbons). Accordingly, the gas feed stream maybe separated into a hydrocarbon-rich (residual) stream on the exteriorof the membrane fiber and a CO₂-rich (permeate) stream on the interiorof the membrane fiber.

It will be appreciated that the CO₂ removal module 222 may be adaptableto various gas volumes, CO₂ concentrations, and/or fuel gasspecifications. Moreover, operational parameters of the CO₂ removalmodule, such as pressure difference between the feed gas and permeategas and/or concentration of the permeating component, may be monitoredand/or controlled via various equipment in communication with the remoteMC system.

In another embodiment, the CO₂ removal module 222 may comprise an aminesorbent system. As known in the art, such systems are adapted to absorbCO₂ and then desorb the CO₂ to atmosphere.

In one embodiment, the natural gas processing system 200 may include adesulfurization module 224 adapted to remove sulfur 295 from the gasstream. Generally, sulfur exists in natural gas as hydrogen sulfide(H₂S), and the natural gas will typically require desulfurization whenits H₂S content exceeds about 0.01 lbs/Mscf. It will be appreciated thatgas containing high levels of H₂S (i.e., “sour gas”) is undesirablebecause it is both corrosive to equipment and dangerous to breathe.

The desulfurization module 224 may employ various technologies to“sweeten,” or remove sulfur from, sour gas. In one embodiment, thedesulfurization module 224 may employ dry sorbents to capture sulfurgases in solid form (e.g., as sulfates or sulfites). In one suchembodiment, a fine sorbent may be injected into the feed gas and theresulting sulfur-containing solids 295 may be collected. Exemplary drysorbents that may be employed include, but are not limited to, calciumoxide, magnesium oxide, and sodium carbonate.

In an alternative embodiment, the desulfurization module 224 maycomprise a wet scrubber subsystem, such as venturi, packed-column, ortray-type systems. In this embodiment, the feed gas may be contactedwith a scrubbing solution or slurry to absorb the H₂S and convert it tomercaptans, which are then drained from the spent bed in liquid form.

In yet another embodiment, the desulfurization module 224 may employamine solutions to remove H₂S. During this process, the feed gas is runthrough a tower containing an amine solution that absorbs sulfur.Exemplary amine solutions may include, but are not limited to,monoethanolamine (“MEA”) and diethanolamine (“DEA”). In one suchembodiment, the amine solution may be regenerated (i.e., the absorbedsulfur may be removed) and reused.

In certain embodiments, the sulfur-containing discharge 295 may bediscarded. However, in other embodiments, the sulfur may be reduced toits elemental form via further processing and then sold. One exemplaryprocess employed to recover sulfur is known as the “Claus process” andinvolves using thermal and catalytic reactions to extract the elementalsulfur from the hydrogen sulfide solution.

It will be appreciated that, no matter which of the above technologiesis employed by the desulfurization module 224, a resulting gas streammay be produced that is virtually free of sulfur compounds. That is, theresulting gas stream may comprise a sulfur content of less than about0.01 lbs/Mscf.

The natural gas processing system 200 may additionally or alternativelycomprise a dehydrator module 226 adapted to remove water 296 from thegas stream. Generally, the dehydrator module 226 may be employed toreduce the moisture content of the gas stream to about 7 lbs/Mscf orless. This mitigates the risk of damage to pipes and process equipmentfrom blocked flow and corrosion.

In one embodiment, the dehydrator module 226 may comprise any number ofdryer beds including one or more desiccants. Exemplary desiccantsinclude, but are not limited to: activated charcoal/carbon, alumina,calcium oxide, calcium chloride, calcium sulfate, silica, silicaalumina, molecular sieves (e.g., zeolites), and/or montmorillonite clay.In one particular embodiment, desiccant materials may be present in apacked-bed configuration.

It will be appreciated that most desiccants have a limited adsorptioncapacity and must be replaced or regenerated at given service intervals.Accordingly, for continuous dehydration service, a multi-bed system maybe employed where one or more beds are utilized while the others arebeing replaced/regenerated. The active bed(s) can then be switched inand out of service as required or desired.

In another embodiment, the dehydrator module 226 may comprise aTriethylene Glycol (“TEG”) system. This system contacts the wet gas withTEG, which absorbs the water from the wet gas stream to produce a richTEG stream. The rich TEG stream is heated with a gas-fired heater andthe water is driven off in the form of water vapor to atmosphere. Thelean TEG stream may then be cooled and pumped back to contact the gasstream.

In other embodiments, the dehydrator module 226 may remove water throughthe use of additives, such as methanol or ethylene glycol, which may besprayed into the natural gas stream to suppress the freezing point ofliquid water. In yet other embodiments, dehydration may comprise anumber of steps, including active dehydration, depressurization,regeneration, and repressurization.

In certain embodiments, the natural gas processing system 200 mayinclude a refrigeration module 230 comprising one or more mechanicalrefrigeration units (“MRU”). Generally, the refrigeration module may beemployed to cool natural gas in an effort to reduce the hydrocarbon dewpoint of the gas (e.g., to meet pipeline quality specifications) and/orto maximize NGLs recovery (e.g., to improve the overall monetary returnof a natural gas stream).

In one embodiment, the refrigeration module 230 may be adapted to lowerthe temperature of the received gas stream to a target temperature, suchthat NGLs comprising propane and higher hydrocarbons (C3+) 297 may beseparated therefrom. The target temperature may be selected to allow theNGLs stream 297 to be condensed (e.g., in a single column), withoutcondensing substantial amounts of methane or ethane. Accordingly, thecondensed NGLs stream 297 may be separated and transported for sale viatruck, rail or pipe; and the resulting fuel gas stream 202, whichcomprises mostly methane and ethane, may be transferred to theelectrical power generation module.

In certain embodiments, the refrigeration module 230 may lower thetemperature of the received gas stream via heat exchange with a lowtemperature fluid (i.e., a refrigerant). Exemplary refrigerants include,but are not limited to, propane, propylene (C₃H₆), n-butane, and/orethylene (C₂H₄). It will be appreciated that other hydrocarbon andnon-hydrocarbon refrigerants may additionally or alternatively beemployed.

Generally, the refrigeration module 230 may cool the received gas streamto a target temperature of from about −10° F. to about −32° F.,depending on the composition of the received gas stream. During cooling,the pressure may be adjusted to, or maintained at, from about 70 psi toabout 510 psi.

In one particular embodiment, the refrigeration module 230 may comprisea cascade refrigerator that employs two or more refrigeration stages inseries to achieve a lower temperature than is otherwise achievable in asingle stage. For example, the refrigerator may cool the gas to a firsttemperature during a first stage (i.e., a “high stage”), and then coolthe gas to a second temperature that is lower than the first temperatureduring a second stage (i.e., a “low stage”).

It will be appreciated that operational parameters of the refrigerationmodule 230 may be monitored and/or controlled across any number ofrefrigeration units via various equipment in communication with theremote MC system. Such operational parameters may include, but are notlimited to, temperature and/or coolant recirculation rate.

It will be appreciated that many aspects of the system 200 depicted inFIG. 2 may be modified or altered to produce fuel gas 202 from rawnatural gas 201 received from one or more wellheads 209 in an oil andgas reservoir. The illustrated system 200 is exemplary, and is intendedto show broadly the relationship between the various aspects of thesystem.

Electrical Power Generation System

FIGS. 3-4 show exemplary electrical power generation systems (300, 400)according to various embodiments. FIG. 3 shows an exemplary electricalpower generation system 300 comprising a power generation module 331 inelectrical communication with an electrical transformation module 335.And FIG. 4 shows an exemplary electrical power generation system 500comprising a plurality of power generation modules (431 a, 431 b) in aparallel configuration, wherein such modules are in electricalcommunication with a single electrical transformation module 435.

Referring to FIG. 3, an exemplary electrical power generation system 300is illustrated. As shown, the system 300 comprises a power generationmodule 331 in communication with a gas supply line 320 such that it mayreceive fuel gas 302 therefrom. The power generation module 331 isfurther shown to be in electrical communication with an electricaltransformation module 335 such that an electrical output 303 may betransmitted from the power generation module to the electricaltransformation module.

Generally, the power generation modules 331 may comprise a generatorcomponent adapted to convert fuel gas 302 into electrical energy 303,various equipment for monitoring and controlling the generatorcomponent, and ancillary equipment to support the generator component.As discussed below, each of these components may be contained within aprotective housing such that the entire power generation module 331 istransportable.

In one embodiment, the power generation module 331 may comprise agenerator component adapted to generate an electrical output 303 viacombustion of the fuel gas 302. Generally, the generator component mayemploy either a fuel-gas-driven reciprocating engine or afuel-gas-driven rotating turbine to combust the fuel gas 302 and drivean electrical generator.

The generator component may be associated with various properties, suchas various input fuel requirements, a fuel gas consumption rate and anelectrical output. The input fuel requirements of a given generatorcomponent specify the required properties of fuel received by thegenerator. As discussed above, the employed power generation modules 331may be specified to operate with fuel gas 302 having a wide variety ofproperties. For example, certain modules may include a generatorcomponents adapted to utilize rich gas, delivered directly downstream ofa separator module. Additionally or alternatively, the power generationmodule 331 may comprise a generator adapted to utilize fuel gas that hasbeen processed to such that it is substantially free of propane andhigher hydrocarbons (C3+) components.

The fuel gas consumption rate of a given generator refers to the volumeof fuel gas consumed by the generator within a given time period. Thefuel gas consumption rate may be determined for continuous operation ofthe generator at standard ambient conditions. Generally, the fuel gasconsumption rate of engine-type generators may range from about 40 Mscfdto about 500 Mscfd. And the fuel gas consumption rate of turbine-typegenerators may range from about 1 MMscfd to about 6 MMscfd.

Electrical output refers to the electrical energy output by a givengenerator after efficiency losses within the generator. This property isoften referred to as “real power” or “kWe.” The electrical output may beprovided as “continuous power,” which refers to the real power obtainedfrom the generator when the module is operating continuously at standardambient conditions.

Although nearly any generator may be employed in the power generationmodules 331, it has been found that generators that produce anelectrical output of from about 70 kW to about 30 MW are preferredbecause these sizes correlate with the quantities of fuel available in atypical application.

Generally, engine-type generators may produce an electrical outputranging from about 70 kW to about 2 MW, with an associated voltageranging from about 480 V to about 4.16 kV. And turbine-type generatorsmay produce an electrical output ranging from about 2 MW to 30 MW, withan associated voltage ranging from about 4.16 kV to about 12 kV.

It will be appreciated that the various generator components employed inthe power generation module 331 may be adapted to operate reliably inharsh oilfield conditions, and with variability in gas rates,composition and heating values. Moreover, it will be appreciated thatthe specific generator employed in a power generation module 331 may beselected and configured based on the specifications of the raw naturalgas and the amount of such raw natural gas that is produced at thewellhead.

As shown, the power generation module 331 may be in furthercommunication with a backup fuel supply 337 containing a backup fuel308. In one embodiment, the backup fuel supply 337 may comprise anatural gas storage tank containing pressurised natural gas (e.g.,received from the natural gas processing system). In another embodiment,the backup fuel supply 337 may comprise an on-site reserve of propane.At times of low wellhead gas pressure, the backup fuel 308 may be pipeddirectly to the generator of the power generation module 331, from thebackup fuel supply 337.

In one embodiment, the power generation module 331 may be adapted toautomatically switch between the fuel gas 302 and the backup fuel 308.In such embodiments, the generator may utilize fuel gas 302 as long asthe pressure and/or flow rate of the fuel gas is greater than or equalto a predetermined value (e.g., from about 20 psig to about 25 psig);and the generator may switch to the backup fuel 308 when the pressureand/or flow rate drops below the predetermined value. It will beappreciated that the fuel switching process may be seamless, resultingin uninterrupted electrical power generation regardless of instantaneousnatural gas supply rates.

In one embodiment, the power generation module 331 may comprise variousmonitoring and control equipment in direct communication with thegenerator component and in remote communication with the MC system(e.g., via a network). Such equipment may allow for automatic monitoringof operational parameters, including but not limited to, fuel gas supplypressure, fuel gas flow rate, fuel gas characteristics, electricaloutput (e.g., frequency, voltage, amperage, etc.) and/or emissions. Andthis configuration may further allow for automatic and/or manual controlof the generator, which enables greater reliability and efficiency inremote oilfield locations where human operators are not always present.

Typically, the power generation module 331 will further comprise variousancillary components (commonly referred to as the “balance of plant”).Such components may include, but are not limited to, compressors,lubrication systems, emissions control systems, catalysts, and exhaustsystems.

As an example, the power generation module 331 may comprise integratedemissions reduction technologies, such as but not limited to, anon-selective catalytic reduction (“NSCR”) system or a selectivecatalytic reduction (“SCR”) system. However, even without employing suchemissions technology, the internal combustion process employed by thedisclosed embodiments, may significantly reduce emissions of NO_(x), COand volatile organic compounds (“VOCs”) relative to flaring. Forexample, an exemplary electrical power generation system 300 that doesnot include an NSCR or SCR may reduce emissions of such compounds byabout 95% or more, as compared to flaring (e.g., at least 95%, at least96%, at least 97%, at least 98%, or at least 99%).

It will be appreciated that emissions monitoring and control are keypermitting requirements in the oilfield. By reducing emissions, thedisclosed embodiments help oil and gas operators achieve environmentaland regulatory benefits as well as improved community relationships.

In one embodiment, the power generation module 331 may comprise ahousing designed to contain and protect the above-described componentsof the module. Such housing may provide features such as, but notlimited to, weatherproofing, skid or trailer mounting for portability,and sound attenuation.

In certain embodiments, the power generation module 331 may be supportedby a transportable chassis, trailer, or railcar to facilitatepositioning and/or repositioning of the module. More particularly, thetransportable chassis, trailers, or railcars may be coupled to vehicles,such as trucks or trains, and transported over a geographic area. Thegenerator skids can range in size from an enclosed trailer hauled behinda pickup truck, to a plurality of semi-trailer loads for the generatorand its required ancillary equipment.

As shown, the electrical power generation system 300 further comprisesan electrical transformation module 335 in electrical communication withthe power generation module 331. Generally, the electrical power 303generated by the power generation module 331 may be transmitted throughthe electrical transformation module 335 such that it may be convertedinto an electrical flow 305 that is suitable for consumption bycomputing equipment (e.g., a mobile data center and any number of DCUsof a distributed computing system).

To that end, the electrical transformation module 335 may comprise powerconditioning equipment typically including one or more step-downtransformers. Such module 335 may be adapted to reduce the voltage of anincoming electrical flow 303 by one or more “steps down” into asecondary electrical flow 305 comprising a lower voltage.

In one embodiment, the electrical transformation module 335 may comprisea 1 MVA step-down transformer adapted to step down the voltage of anincoming electrical flow 303 having a voltage of from about 480 V toabout 4.16 kV. In such cases, the electrical transformation module 335may convert the incoming electrical flow 303 to a reduced-power outputelectrical flow 305 having a voltage of about 208 V or about 240 V.

Alternatively, when larger turbine-type power generation modules 331 areemployed, the electrical transformation module 335 may reduce voltage ina plurality of steps. For example, the electrical transformation modulemay receive an incoming electrical flow 303 having a voltage of fromabout 4.16 kV to about 12 kV to and may step down the voltage to about480 V in a first step. And the module may then further reduce thevoltage, via one or more additional steps down, in order to provide areduced-power output electrical flow 305 having a voltage of about 208V.

In certain embodiments, the electrical transformer module 335 may alsocomprise a main breaker capable of cutting off all downstream electricalflows, which allows an operator to quickly de-power any attachedcomputing equipment in the case of operational work or emergencyshut-down. Additionally or alternatively, terminals of the electricaltransformation module 335 may be fitted with “quick connects,” which arepre-terminated inside the module. Such quick connects allow oilfieldelectricians to quickly connect the electrical transformation module 335to the power generation module 331 and to a component of the distributedcomputing system without extensive on-site fabrication and terminationwork.

In the illustrated embodiment, only one power generation module 331provides electrical power 303 to the electrical transformation module335. Accordingly, the power generation module 331 may be directly wiredfrom a terminal of the power generation module 331 into a primary sideof the electrical transformation module 335.

Although only one power generation module 331 and one electricaltransformation module 335 is shown in FIG. 3, it will be appreciatedthat any number of such components may be included in the powergeneration system 300. For example, two or more sets of power generationmodules 331 and electrical transformation modules 335 may be employed,in a series configuration, to power any number of computing components(e.g., mobile data centers and DCUs).

Generally, such equipment may be added and/or removed, as required, toconsume substantially all available natural gas supply. Moreover, thespecific generators employed in the power generation modules 331, thenumber of such modules, and the configuration of such modules may alsobe selected with this goal in mind. For example, such equipment may beselected, configured, added to and/or removed from the electrical powergeneration system 300, as necessary to allow the system to consume atleast about 75% (e.g., at least about 80%, at least about 85%, at leastabout 90%, or at least about 95%) of the natural gas supply. In thisway, the system 300 may substantially reduce the amount of natural gasthat must be flared during oil production.

Referring to FIG. 4, another exemplary electrical power generationsystem 400 is illustrated. As shown, the system 400 comprises aplurality of power generation modules (431 a, 431 b) in communicationwith a gas supply line 420 such that they may receive fuel gas 402therefrom. The power generation modules (431 a, 431 b) are also inelectrical communication with an electrical transformation module 435via a parallel panel 460. And, as discussed above, the power generationmodules (431 a, 431 b) may be in communication with one or more backupfuel supplies 437, such that they may receive backup fuel 408 (e.g.,propane) therefrom.

As shown, the electrical power generation system 400 may comprisemultiple power generation modules (431 a, 431 b) connected in parallelto a single electrical transformation module 435. In such embodiments,the multiple electrical power generation modules (431 a, 431 b) may bephase-synced such that their output electrical flows (403 a, 403 b) maybe combined down-stream without misalignment of wave frequency.

Specifically, the multiple phase-synced electrical flows (403 a, 403 b)may be wired into a parallel panel 460, which merges and synchronizesthe electrical flows into a single down-stream flow 404 with singularvoltage, frequency, current and power metrics. This singular down-streamflow 404 may then be wired into a primary side of an electricaltransformation module 435 for voltage modulation. For example, asdiscussed above, the singular down-stream flow 404 may be transmitted tothe electrical transformation module 435 such that the flow may beconverted into an output electrical flow 405 that is suitable forconsumption by computing equipment (e.g., one or more mobile datacenters of a distributed computing system including any number of DCUs).

In such embodiments, each of the power generation modules (431 a, 431 b)and/or the parallel panel 460 may comprise a control system that allowsfor the module to be synchronized and paralleled with other powergeneration modules. The control system may allow load-sharing of up to32 power generation modules via a data link and may provide powermanagement capabilities, such as load-dependent starting and stopping,asymmetric load-sharing, and priority selection. Such functionality mayallow an operator to optimize load-sharing based on running hours and/orfuel consumption.

Distributed Computing System

Referring to FIG. 5, an exemplary distributed computing system 500according to an embodiment is illustrated. As shown, the system 500 mayinclude one or more mobile data centers 510 comprising variouselectrical components, such as but not limited to: any number of DCUs520, a communications system 555, an electrical power system 530, abackup power system 540, and/or a monitoring and control system 580.

Generally, each of the mobile data centers 510 may comprise aprefabricated housing or enclosure to contain and protect the variouselectronics. The enclosure may comprise a customized shipping containeror other modular housing system designed for portability, durability,safety, stack-ability, ventilation, weatherproofing, dust control andoperation in rugged oilfield conditions.

As shown, each of the mobile data centers 510 may comprise an electricalpower system 530 adapted to receive electrical power 505 from anelectrical transformation module of an electrical power generationsystem, as discussed above. More particularly, the power system 530 mayreceive an output electrical flow 505 from a secondary terminal of anelectrical transformation module via cable trays, buried lines and/oroverhead suspended lines. In certain embodiments, each mobile datacenter 510 may be fitted with quick connects (discussed above), whichare pre-terminated into the power system 530.

In one embodiment, the electrical power system 530 may comprise one ormore breaker panels in electrical communication with a series of powerdistribution units (“PDUs”) or power channels. Such PDUs may also be incommunication with the various electrical components of the mobile datacenter 510, such as DCUs 520, backup power systems 540 (e.g., batteriesand/or solar panels), a communication system 555, and/or a monitoringand control system 580.

In certain embodiments, the breaker panels and/or PDUs of the powersystem 530 may be in communication with a monitoring and control system580 of the mobile data center 510. And such monitoring and controlsystem 580 may be in communication with the remote MC system (FIG. 1 at180) via a network such that an operator may remotely control (activateand/or deactivate) these components and all electrical equipment inelectrical communication therewith. This remote power control feature isimportant for efficiency and cost reduction in remote oilfieldlocations, where a human operator may not be present. For example, PDUsmay be remotely “power cycled” to reset, reboot or restartmalfunctioning equipment without the expense or time required to deploya human. As another example, breaker panel switches may be remotelycontrolled to turn on/off power to downstream systems without the needfor human dispatch.

As shown, each of the mobile data centers 510 may comprise a pluralityof DCUs 520, wherein the DCUs are powered via the power system 530 and,optionally, via the backup power system 540. As discussed above, theDCUs are adapted to conduct any number of processing-intensive tasks,such as but not limited to, graphics-intensive distributed computingprocesses, server functions, storage, virtual reality and/or augmentedreality applications, tasks relating to the Golem Project, non-currencyblockchain applications and/or cryptocurrency mining operations.

It will be appreciated that the number of mobile data centers, thenumber of DCUs contained in each mobile data center, and/or theprocessing power of such DCUs may be selected to utilize substantiallyall electrical power generated by the electrical power generationsystem. Moreover, such equipment may be added and/or removed from thedistributed computing system 500, as desired or required, to consumesubstantially all electrical power generated by the electrical powergeneration system. For example, the components of the distributedcomputing system may be selected, configured, added and/or removed, asnecessary to allow the system 500 to consume the maximum practicalamount of the power generated by the electrical power generation system(typically in excess of 90% of the available power). This allows forrevenue generated from distributed computing tasks to be maximized,while also maximizing consumption of produced natural gas via theelectrical power generation system.

As discussed above, the mobile data centers 510 and the variouselectronic components contained there (e.g., DCUs 520, monitoring andcontrol system 580, power system 530 and/or backup power system 540) maybe connected to a network via wired or wireless connection to acommunication system 555. The communication system 555 may comprise oneor more modems, network switches, and network management computers toprovide connectivity to the network, such as the Internet, via a fiberoptic cable, fixed point wireless (laser, millimeter wave towers,microwave towers or the like used to relay high speed internet on aline-of-sight basis), satellite internet, cell-based internet or anyother means of internet connection. And the components of thecommunication system 555 may be distributed throughout the mobile datacenter 510 as required to connect all DCUs 520 into the network and tosupply sufficient data input and output bandwidth for all connectedcomponents.

It will be appreciated that heat and airflow management are importantconsiderations when operating in an oilfield, as outside airtemperatures may vary widely from extreme cold to extreme heat.Moreover, excessive dust and precipitation must also be monitored andcontrolled during oilfield operation. Accordingly, in one embodiment,the monitoring and control system 580 may be adapted to control variousparameters of the mobile data center 510, such as temperature, moisture,oxygen, power and/or others.

In one embodiment, the mobile data center 510 may be designed with acold aisle and a hot aisle. For example, the DCUs 520 may be locatedwithin vertically stacked, horizontal racks extending along a row withinthe mobile data center; and all of the DCUs may be positioned within theracks such that their intake fans point towards the cold aisle, whiletheir exhaust fans point in an opposite direction, towards the hotaisle. It will be appreciated that one or more air inlets of the mobiledata center 510 may be aligned with the cold aisle and one or moreexhausts of the mobile data center be aligned with the hot aisle.

In one embodiment, the hot and cold aisles may be isolated/separated byemploying a faceplate that extends along the row of stacked DCUs 520,adjacent to the exhaust-side thereof. Generally, the faceplate maycomprise a metal, plastic, composite, wood or other thin and flatmaterial having a plurality of precut apertures disposed therein. Theapertures may be positioned such that each aperture is aligned with anexhaust fan of one of the DCUs. And the apertures may be sized/shaped tocomplement the size/shape of the DCU exhaust fans, such that each fansubstantially fills/covers each aperture and such that each fan maytransmit exhaust through one of the apertures. Accordingly, thefaceplate forms a physical barrier between gaps in DCU exhaust fans,which helps to ensure that hot air does not recirculate from the hotaisle back to the cold aisle.

The hot aisle may be naturally vented to an exterior of the mobile datacenter 510, for example, with direct exhaust via one or more exhaustpanels or vents. Alternatively, the mobile data center may include aforced air exhaust system, wherein exhaust fans force air out of the hotaisle and exhaust to the exterior. In such embodiments, the exhaust fansmay communicate with the monitoring and control system 580 such that thefans may be automatically activated/deactivated as the temperaturewithin the mobile data center increases/decreases.

In another embodiment, the mobile data center 510 may comprise variouslouvers, dampers, filters and/or awnings designed to protect againstdirect and wind-blown precipitation, as well as excessive dust intake.In such cases, dampers may be connected to the monitoring and controlsystem 580 such that they may be automatically closed to seal and themobile data center in the event of a power failure.

It will be appreciated that the mobile data center 510 may be furtherdesigned with various safety and security features specific to oilfieldoperations. For example, the mobile data center 510 may comprise one ormore wireless cameras controlled by the monitoring and control system580 and powered by the power system 530 and/or the backup power system540. Such cameras may be specified for continuous remote monitoringand/or motion-activated recording. As another example, the mobile datacenter 510 may comprise motion activated lighting systems that serve asan additional crime deterrent and/or that may provide sufficient lightto facilitate work during nighttime operations.

And as yet another example, the mobile data center 510 may comprise afire suppression system designed to retard gas and electrical fires. Inone embodiment, the monitoring and control system 580 may cause thedampers to automatically seal when extreme temperatures are detected(i.e., to cut off oxygen flow to a fire inside the mobile data center).

Computing Machines

Referring to FIG. 6, a block diagram is provided illustrating anexemplary computing machine 600 and modules 650 in accordance with oneor more embodiments presented herein. The computing machine 600 mayrepresent any of the various computing systems discussed herein, such asbut not limited to, the DCUs (FIG. 5 at 520), the MC system (FIG. 1 at180), the client devices (FIG. 1 at 160) and/or the third-party systems(FIG. 1 at 170). And the modules 650 may comprise one or more hardwareor software elements configured to facilitate the computing machine 600in performing the various methods and processing functions presentedherein.

The computing machine 600 may comprise all kinds of apparatuses,devices, and machines for processing data, including but not limited to,a programmable processor, a computer, and/or multiple processors orcomputers. As shown, an exemplary computing machine 600 may includevarious internal and/or attached components, such as a processor 610,system bus 670, system memory 620, storage media 640, input/outputinterface 680, and network interface 660 for communicating with anetwork 630.

The computing machine 600 may be implemented as a conventional computersystem, an embedded controller, a server, a laptop, a mobile device, asmartphone, a wearable device, a set-top box, over-the-top content TV(“OTT TV”), Internet Protocol television (“IPTV”), a kiosk, a vehicularinformation system, one more processors associated with a television, acustomized machine, any other hardware platform and/or combinationsthereof. Moreover, a computing machine may be embedded in anotherdevice, such as but not limited to, a smartphone, a personal digitalassistant (“PDA”), a tablet, a mobile audio or video player, a gameconsole, a Global Positioning System (“GPS”) receiver, or a portablestorage device (e.g., a universal serial bus (“USB”) flash drive). Insome embodiments, such as the DCUs, the computing machine 600 may be adistributed system configured to function using multiple computingmachines interconnected via a data network or system bus 670.

The processor 610 may be configured to execute code or instructions toperform the operations and functionality described herein, managerequest flow and address mappings, and to perform calculations andgenerate commands. The processor 610 may be configured to monitor andcontrol the operation of the components in the computing machine 600.The processor 610 may be a general-purpose processor, a processor core,a multiprocessor, a reconfigurable processor, a microcontroller, adigital signal processor (“DSP”), an application specific integratedcircuit (“ASIC”), a graphics processing unit (“GPU”), a fieldprogrammable gate array (“FPGA”), a programmable logic device (“PLD”), acontroller, a state machine, gated logic, discrete hardware components,any other processing unit, or any combination or multiplicity thereof.The processor 610 may be a single processing unit, multiple processingunits, a single processing core, multiple processing cores, specialpurpose processing cores, coprocessors, or any combination thereof. Inaddition to hardware, exemplary apparatuses may comprise code thatcreates an execution environment for the computer program (e.g., codethat constitutes one or more of: processor firmware, a protocol stack, adatabase management system, an operating system, and a combinationthereof). According to certain embodiments, the processor 610 and/orother components of the computing machine 600 may be a virtualizedcomputing machine executing within one or more other computing machines.

The system memory 620 may include non-volatile memories such asread-only memory (“ROM”), programmable read-only memory (“PROM”),erasable programmable read-only memory (“EPROM”), flash memory, or anyother device capable of storing program instructions or data with orwithout applied power. The system memory 620 also may include volatilememories, such as random-access memory (“RAM”), static random-accessmemory (“SRAM”), dynamic random-access memory (“DRAM”), and synchronousdynamic random-access memory (“SDRAM”). Other types of RAM also may beused to implement the system memory. The system memory 620 may beimplemented using a single memory module or multiple memory modules.While the system memory is depicted as being part of the computingmachine 600, one skilled in the art will recognize that the systemmemory may be separate from the computing machine without departing fromthe scope of the subject technology. It should also be appreciated thatthe system memory may include, or operate in conjunction with, anon-volatile storage device such as the storage media 640.

The storage media 640 may include a hard disk, a compact disc read onlymemory (“CD-ROM”), a digital versatile disc (“DVD”), a Blu-ray disc, amagnetic tape, a flash memory, other non-volatile memory device, asolid-state drive (“SSD”), any magnetic storage device, any opticalstorage device, any electrical storage device, any semiconductor storagedevice, any physical-based storage device, any other data storagedevice, or any combination or multiplicity thereof. The storage media640 may store one or more operating systems, application programs andprogram modules such as module, data, or any other information. Thestorage media may be part of, or connected to, the computing machine600. The storage media may also be part of one or more other computingmachines that are in communication with the computing machine such asservers, database servers, cloud storage, network attached storage, andso forth.

The modules 650 may comprise one or more hardware or software elementsconfigured to facilitate the computing machine 600 with performing thevarious methods and processing functions presented herein. The modules650 may include one or more sequences of instructions stored as softwareor firmware in association with the system memory 620, the storage media640, or both. The storage media 640 may therefore represent examples ofmachine or computer readable media on which instructions or code may bestored for execution by the processor. Machine or computer readablemedia may generally refer to any medium or media used to provideinstructions to the processor. Such machine or computer readable mediaassociated with the modules may comprise a computer software product. Itshould be appreciated that a computer software product comprising themodules may also be associated with one or more processes or methods fordelivering the module to the computing machine 600 via the network, anysignal-bearing medium, or any other communication or deliverytechnology. The modules 650 may also comprise hardware circuits orinformation for configuring hardware circuits such as microcode orconfiguration information for an FPGA or other PLD.

The input/output (“I/O”) interface 680 may be configured to couple toone or more external devices, to receive data from the one or moreexternal devices, and to send data to the one or more external devices.Such external devices along with the various internal devices may alsobe known as peripheral devices. The I/O interface 680 may include bothelectrical and physical connections for operably coupling the variousperipheral devices to the computing machine 600 or the processor 610.The I/O interface 680 may be configured to communicate data, addresses,and control signals between the peripheral devices, the computingmachine, or the processor. The I/O interface 680 may be configured toimplement any standard interface, such as small computer systeminterface (“SCSI”), serial-attached SCSI (“SAS”), fiber channel,peripheral component interconnect (“PCI”), PCI express (PCIe), serialbus, parallel bus, advanced technology attachment (“ATA”), serial ATA(“SATA”), universal serial bus (“USB”), Thunderbolt, FireWire, variousvideo buses, and the like. The I/O interface may be configured toimplement only one interface or bus technology. Alternatively, the I/Ointerface may be configured to implement multiple interfaces or bustechnologies. The I/O interface may be configured as part of, all of, orto operate in conjunction with, the system bus 670. The I/O interface680 may include one or more buffers for buffering transmissions betweenone or more external devices, internal devices, the computing machine600, or the processor 610.

The I/O interface 680 may couple the computing machine 600 to variousinput devices including mice, touch-screens, scanners, biometricreaders, electronic digitizers, sensors, receivers, touchpads,trackballs, cameras, microphones, keyboards, any other pointing devices,or any combinations thereof. When coupled to the computing device, suchinput devices may receive input from a user in any form, includingacoustic, speech, visual, or tactile input.

The I/O interface 680 may couple the computing machine 600 to variousoutput devices such that feedback may be provided to a user via any formof sensory feedback (e.g., visual feedback, auditory feedback, ortactile feedback). For example, a computing machine can interact with auser by sending documents to and receiving documents from a device thatis used by the user (e.g., by sending web pages to a web browser on auser's client device in response to requests received from the webbrowser). Exemplary output devices may include, but are not limited to,displays, speakers, printers, projectors, tactile feedback devices,automation control, robotic components, actuators, motors, fans,solenoids, valves, pumps, transmitters, signal emitters, lights, and soforth. And exemplary displays include, but are not limited to, one ormore of: projectors, cathode ray tube (“CRT”) monitors, liquid crystaldisplays (“LCD”), light-emitting diode (“LED”) monitors and/or organiclight-emitting diode (“OLED”) monitors.

Embodiments of the subject matter described in this specification can beimplemented in a computing machine 600 that includes one or more of thefollowing components: a backend component (e.g., a data server); amiddleware component (e.g., an application server); a frontend component(e.g., a client computer having a graphical user interface (“GUI”)and/or a web browser through which a user can interact with animplementation of the subject matter described in this specification);and/or combinations thereof. The components of the system can beinterconnected by any form or medium of digital data communication, suchas but not limited to, a communication network. Accordingly, thecomputing machine 600 may operate in a networked environment usinglogical connections through the network interface 660 to one or moreother systems or computing machines across a network.

The processor 610 may be connected to the other elements of thecomputing machine 600 or the various peripherals discussed hereinthrough the system bus 670. It should be appreciated that the system bus670 may be within the processor, outside the processor, or both.According to some embodiments, any of the processor 610, the otherelements of the computing machine 600, or the various peripheralsdiscussed herein may be integrated into a single device such as a systemon chip (“SOC”), system on package (“SOP”), or ASIC device.

Experiments

Experiment 1

In a first experiment, a flare mitigation system was deployed at a wellsite within the Bakken Field. The flare mitigation system included anelectrical power generation system having six engine-type powergeneration modules adapted to receive fuel gas from a fuel gas supplyline. Specifically, the system included a first set of power generationmodules including two 350 kW engine-type power generation modules andone 225 kW engine-type power generation module; and a second set ofpower generation modules that also included two 350 kW engine-type powergeneration modules and one 225 kW engine-type power generation module.

The first set of power generation modules was connected, via a firstparallel panel, to a first electrical transformation module comprising a1 MVA step down transformer. And the second set of power generationmodules was connected, via a second parallel panel, to a secondelectrical transformation module comprising a 1 MVA step downtransformer.

The first electrical transformation module received a first inputelectrical flow from the first parallel panel having a voltage of 480 Vand transformed the flow into a first output electrical flow having avoltage of 208 V. The first output electrical flow was then distributed,via diesel locomotive (“DLO”) cables on a cable tray, to an electricalpower system of a first mobile data center. Specifically, the DLO cableswere distributed to a plurality of breaker panels (e.g., 4 or 5)associated with the first mobile data center; each of the breaker panelswas in electrical communication with 25 to 35 PDUs; and each of the PDUswas in electrical communication with up to 4 DCUs racked within thefirst mobile data center. Accordingly the first set of power generationmodules was able to support from about 400 DCUs to about 700 DCUs(depending on the number of breaker panels and PDUs employed).

The second electrical transformation module received a second inputelectrical flow from the second parallel panel having a voltage of 480 Vand transformed the flow into a second output electrical flow having avoltage of 208 V. The second output electrical flow was then distributedto up to 700 DCUs contained within a second mobile center, substantiallyas described above with respect to the first mobile data center.

Each of the first and second mobile data centers measured approximately40′ by 8′ by 9.5′ (e.g., the size of a High Cube shipping container).Both mobile data centers employed forced air with cold air enteringthrough louvered, screened and filtered intakes on one long axis, andhot air exhausting through louvered and screened fan exhausts on theother long axis.

The above system was found to consume fuel gas at a rate of about 300Mscfd. The system was further found to generate an electrical output ofabout 2 MW, wherein substantially all of such electrical output wasutilized to power the DCUs contained within the mobile data centers.

Experiment 2

In a second experiment, a flare mitigation system was deployed at a wellsite within the D-J Basin. The flare mitigation system included anelectrical power generation system having three engine-type powergeneration modules adapted to receive fuel gas from a fuel gas supplyline. A first 1.8 MW engine-type power generation module was connectedto both a first electrical transformation module and a second electricaltransformation module. A second 1.8 MW engine-type power generationmodule was connected to both a third and a fourth electricaltransformation module. And a third 1.8 MW engine-type power generationmodule was connected to both a fifth and a sixth electricaltransformation module.

Each of the first, second, third, fourth, fifth and sixth electricaltransformation modules comprised a 1 MVA step-down transformer adaptedto receive a 480 V input electrical flow from a respective, connectedpower generation module and to transform such flow into an outputelectrical flow having a voltage of 208 V or 240 V. Each of the sixelectrical transformation modules was also in electrical communicationwith a separate mobile data center (substantially as described abovewith respect to Experiment 1), such that a total of six mobile datacenters comprising a total of 2,100 DCUs were powered via the three 1.8MW power generation modules.

The above system was found to consume fuel gas at a rate of about 900Mscfd. The system was further found to generate an electrical output ofabout 5.4 MW, wherein substantially all of such electrical output wasutilized to power the DCUs contained within the mobile data centers.

Experiment 3

In a third experiment, a flare mitigation system was deployed at a wellsite within the D-J Basin. The flare mitigation system included anelectrical power generation system comprising a 350 kW or 385 kWengine-type power generation module adapted to receive fuel gas from afuel gas supply line. The power generation module was connected to anelectrical transformation module comprising a 0.5 MVA step-downtransformer, which transformed a 480 V electrical flow from thegenerator to a 208 V or 240 V output electrical flow (as describedabove).

The output electrical flow was then distributed to an electrical powersystem of a single 20′ by 8′ by 9.5′ mobile data center, which employedpower channels (rather than PDUs to support 264 DCUs). For ventilation,the mobile data center utilized natural aspiration via direct exhaust ofDCUs to the container's exterior. Specifically, the mobile data centerincluded a pair of awnings and protective walls extending from the airintake (a wall of metal gridding and filtration material on one longaxis), as well as the air exhaust wall (a metal grid against which DCUexhaust fans were mounted directly on the other long axis).

The above system was found to consume fuel gas at a rate of about 70Mscfd to about 80 Mscfd. Moreover, it was found that, in some cases, twoparalleled 170 kW engine-type generators could be substituted for asingle 350 kW or 385 kW engine-type generator.

Various embodiments are described in this specification, with referenceto the detailed discussed above, the accompanying drawings, and theclaims. Numerous specific details are described to provide a thoroughunderstanding of various embodiments. However, in certain instances,well-known or conventional details are not described in order to providea concise discussion. The figures are not necessarily to scale, and somefeatures may be exaggerated or minimized to show details of particularcomponents. Therefore, specific structural and functional detailsdisclosed herein are not to be interpreted as limiting, but merely as abasis for the claims and as a representative basis for teaching oneskilled in the art to variously employ the embodiments.

The embodiments described and claimed herein and drawings areillustrative and are not to be construed as limiting the embodiments.The subject matter of this specification is not to be limited in scopeby the specific examples, as these examples are intended asillustrations of several aspects of the embodiments. Any equivalentexamples are intended to be within the scope of the specification.Indeed, various modifications of the disclosed embodiments in additionto those shown and described herein will become apparent to thoseskilled in the art, and such modifications are also intended to fallwithin the scope of the appended claims.

It will be understood by those skilled in the art that the drawings arediagrammatic and that further items of equipment such as temperaturesensors, pressure sensors, pressure relief valves, control valves, flowcontrollers, level controllers, holding tanks, storage tanks, and thelike may be required in a commercial plant.

While this specification contains many specific implementation details,these should not be construed as limitations on the scope of anyinvention or of what may be claimed, but rather as descriptions offeatures that may be specific to particular embodiments of particularinventions. Certain features that are described in this specification inthe context of separate embodiments can also be implemented incombination in a single embodiment. Conversely, various features thatare described in the context of a single embodiment can also beimplemented in multiple embodiments separately or in any suitablesubcombination. Moreover, although features may be described above asacting in certain combinations and even initially claimed as such, oneor more features from a claimed combination can in some cases be excisedfrom the combination, and the claimed combination may be directed to asubcombination or variation of a subcombination.

Similarly, while operations are depicted in the drawings in a particularorder, this should not be understood as requiring that such operationsbe performed in the particular order shown or in sequential order, orthat all illustrated operations be performed, to achieve desirableresults. In certain circumstances, multitasking and parallel processingmay be advantageous. Moreover, the separation of various system modulesand components in the embodiments described above should not beunderstood as requiring such separation in all embodiments, and itshould be understood that the described program components and systemscan generally be integrated together in a single software product orpackaged into multiple software products.

All references including patents, patent applications and publicationscited herein are incorporated herein by reference in their entirety andfor all purposes to the same extent as if each individual publication orpatent or patent application was specifically and individually indicatedto be incorporated by reference in its entirety for all purposes.

What is claimed is:
 1. A method comprising: receiving, by a powergeneration system, a fuel gas stream comprising a fuel gas having a heatvalue of at least about 1,000 Btu/scf; generating, by the powergeneration system, from the fuel gas, a high-voltage electrical outputassociated with a first voltage, wherein said generating is performed bya power generation module of the power generation system, the powergeneration module including a generator component adapted to convert thefuel gas into electrical energy, the power generation module furtherincluding monitoring and control equipment, the monitoring and controlequipment of the power generation module being in direct communicationwith the generator component and in remote communication with amonitoring and control system, transforming, by the power generationsystem, the high-voltage electrical output into a low-voltage electricaloutput associated with a second voltage that is lower than the firstvoltage; powering, by the power generation system, via the low-voltageelectrical output, a plurality of distributed computing units;automatically monitoring, by the monitoring and control equipment of thepower generation module, one or more operational parameters of the powergeneration module and controlling the generator component; and upondetermining a change in the one or more operational parameters of thepower generation module, modulating an electrical load of the pluralityof distributed computing units by the monitoring and control system. 2.A method according to claim 1, wherein: the one or more operationalparameters of the power generation module include a temperatureassociated with a location within the power generation module.
 3. Amethod according to claim 1, wherein the plurality of distributedcomputing units are adapted to mine a cryptocurrency.
 4. A methodaccording to claim 3, wherein the plurality of distributed computingunits are disposed within one or more mobile data centers.
 5. A methodaccording to claim 4, wherein the one or more mobile data centerscomprises at least two mobile data centers.
 6. A method according toclaim 1, wherein the fuel gas stream is received from a natural gasprocessing system.
 7. A method according to claim 1, wherein: thehigh-voltage electrical output is from about 70 kW to about 2 MW; thefirst voltage is from about 480 V to about 4.16 kV; and the secondvoltage is from about 208 V to about 240 V.
 8. A method according toclaim 1, wherein: the high-voltage electrical output is from about 1 MWto about 2 MW; and the first voltage is about 480 V.
 9. A methodaccording to claim 1, wherein: the high-voltage electrical outputcomprises from about 2 MW to about 30 MW; the first voltage is fromabout 4.16 kV to about 12 kV; and the second voltage is from about 208 Vto about 240 V.
 10. A method according to claim 1, wherein the one ormore operational parameters of the power generation module include acomposition of the fuel gas.
 11. A method according to claim 1, whereinthe one or more operational parameters of the power generation moduleinclude a fuel gas supply pressure.
 12. A method according to claim 1,wherein the one or more operational parameters of the power generationmodule include a fuel gas flow rate.
 13. A method according to claim 1,wherein the one or more operational parameters of the power generationmodule include fuel gas characteristics.
 14. A method according to claim1, wherein the one or more operational parameters of the powergeneration module include emissions.
 15. A method according to claim 1,wherein the monitoring and control equipment include sensors at thepower generation system.
 16. A method comprising: receiving, by a powergeneration system, a fuel gas stream comprising a fuel gas having a heatvalue of at least about 1,000 Btu/scf; generating, by a power generationmodule of the power generation system, from the fuel gas, a high-voltageelectrical output associated with a first voltage; and transforming, bythe power generation system, the high-voltage electrical output into alow-voltage electrical output associated with a second voltage that islower than the first voltage; powering, by the power generation system,via the low-voltage electrical output, a plurality of distributedcomputing units; monitoring, by monitoring and control equipment,operational parameters of the power generation module, the monitoringand control equipment being in direct communication with the powergeneration module and in remote communication with a monitoring andcontrol system; and automatically modulating, by the monitoring andcontrol system, based on the monitored operational parameters, anelectrical load of the plurality of distributed computing units.
 17. Amethod according to claim 16, wherein the operational parameterscomprise a composition of the fuel gas.
 18. A method according to claim16, wherein the operational parameters comprise a temperature associatedwith a location within the power generation module.
 19. A methodaccording to claim 16, wherein the plurality of distributed computingunits are adapted to mine a cryptocurrency.
 20. A method according toclaim 19, wherein the plurality of distributed computing units aredisposed within one or more mobile data centers.
 21. A method accordingto claim 20, wherein the one or more mobile data centers comprises atleast two mobile data centers.
 22. A method according to claim 16,wherein the fuel gas stream is received from a natural gas processingsystem.
 23. A method according to claim 16, wherein the operationalparameters comprise a fuel gas supply pressure.
 24. A method accordingto claim 16, wherein the operational parameters comprise a fuel gas flowrate.
 25. A method according to claim 16, wherein the operationalparameters comprise fuel gas characteristics.
 26. A method according toclaim 16, wherein the operational parameters comprise emissions.
 27. Amethod according to claim 16, wherein the monitoring and controlequipment include sensors at the power generation system.